88082%0 ( 85gg7 880811 86

TENNESSEE VALLEY AUTHORlTY

Sequoyah Nuclear PlantPE 0. Box 2000

Soddy-Daisy, Tennessee 37379

AUG 11 1988

Nuclear Regulatory CommissionOffice of Management Information

and Program ControlWashington, DC 20555

Gentlemen:

Enclosed is the July 1988 Monthly Operating Report to NRC for SequoyahNuclear Plant.

Very truly yours,

TENNESSEE VALLEY AUTHORITY

S. J. SmithPlant Manager

Enclosurecc (Enclosure):

Director, Region IINuclear Regulatory CommissionOffice of Inspection and EnforcementSuite 3100101 Marietta StreetAtlanta, Georgia 30323 (1 copy)

Director, Office of Inspectionand Enforcement

Nuclear Regulatory CommissionWashington, DC 20555 (12 copies)

INPO Records CenterSuite 15001100 Circle 75 ParkwayAtlanta, Georgia 30339 (1 copy)

Mr. K. M. JenisonResident NRC InspectorOOPS-2, Sequoyah Nuclear Plant

DirectorOffice of Special Projects4350 East West Highway, EWW 322Bethesda, Maryland 10814 (10 copies)

Mr. T. MarstonElectric Power Research InstituteP. 0. Box 10412Palo Alto, California 94304 (1 copy)

M pp'n Equal Opportunity EmployerI

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Nuclear Re ory Commission

AU I $88

cc (Enclosure):RIMS, MR 4N 72A-CJ. R. Bynum, LP 6N 38A-CJ. P. Darling, Site Director, BLNC. H. Fox, Jr., LP 6N 38A-CR. L. Gridley, LP 5N 157B-CW. H. Hannum, BR 1N 77B-CR. J. Johnson, MBC 01 DS-PTCN. C. Kazanas, LP 4N 45A-CJ. A. Kirkebo, W12 A12 C-KW. R. Lagergren, LP 6N 38A-CJ. T. LaPoint, 0&PS-4, SequoyahC. C. Mason, LP 6N 38A-CR. U. Mathieson, Westinghouse, SQNJ. L. McAnally, LP 5S 83E-CB. R. McCullough, 9-167 SB-KG. R. Mullee, BR 5S 168A-CR. A. Pedde, Site Director, WBN

H. P. Pomrehn, Site Director, BFNR. A. Remington, 0&PS-4, SQNVwe Zitzow, LP 5S 98E-CNuclear Site Representative, BFNNuclear Site Representative, WBN

This was prepared principally by D. C. Dupree.

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TENNESSEE VALLEY AUTHORITY

NUCLEAR POWER GROUP

(FORMERLY OFFICE OF NUCLEAR POWER)SEQUOYAH NUCLEAR PLANT

MONTHLY OPERATING REPORT

TO THE

NUCLEAR REGULATORY COHMISSION

JULY 1988

UNIT lDOCKET NUMBER 50-327

LICENSE NUMBER DPR-77

UNIT 2

DOCKET NUMBER 50-328

LICENSE NUMBER DPR-79

Submitted by: I

S. J. Smith, Plant Manager

TABLE OF CONTENTS

Page

I. Operational Summary

Performance SummarySignificant Operational EventsFuel Performance and Spent Fuel Storage

CapabilitiesMiscellaneousPORVs and Safety Valves SummarySpecial ReportsLicensee EventsRadwaste SummaryOffsite Dose Calculation Manual Changes

11-3

4445

5-101111

II. Operating Statistics

A. NRC Reports

Unit One StatisticsUnit Two Statistics

12-1415-17

B. TVA Reports

Nuclear Plant Operating StatisticsUnit Outage and Availabil~tyReactor Histogram

III. Maintenance Summary

1819-2021-23

Electrical MaintenanceInstrument MaintenanceMechanical MaintenanceModifications

2425-2627-3031-38

IV. Corrections 39-40

0288f/dlr

OPERATIONAL SUMMARY

PFRFORMANCE SUMMARY

~Jul 1888

The following summary describes the significant operational activities for themonth of July. 'In support of this summary, a chronological log of significantevents is included in this report.

Unit 1 remained in an administrative shutdown the entire month because ofdesign control review, configuration control updating, and resolut:on ofsignificant employee concerns. Outage-re'c' d maintenance and modi.ficatic„ sare being performed in preparation or restart. Unit 1 has been off line1,074 days.

Unit 2 entered the month of July at 70 percent power, producing 770 MWe andwas online the entire month. On July 17, 1988, the unit reached 98 percentreactor power. On July 24, 1988, unit two had produced over 1,000,000megawatt hours (1,025,474 MWhs) of power since restart and has been incontinuous operation for 39 days. The capacity factor for the month was77.60 percent.

SIGNIFICANT OPERATIONAT EVENTS

Unit 1

Date Time Event

07/01/88 0001E The reactor was in mode 5. The administrative shutdowndue to design control review, configuration controlupdating, and resolution of significant employeeconcerns continues.

07/31/88 2400E The reactor wa". in mode 5. The administrative shutdowndue to design control review, configuration controlupdating, and resolution of significant employeeconcerns continues.

Unit 2

Date Time Event

07/01/88 0001E Reactor at 70 percent, 770 MWe. Holding for corelife extension.

07/16/88 0300E Began load reduction to 55 percent for maintenance on2A-A and 2B-B main feed pumps (MFP).

0700E

0814E

Reactor at 55 percent, 606 MWe.

Began removing 2A-A from service.

l

SIGNIFICANT OPERATIONAL EVENTS

Unit 2 Continued

Date Time Event

07/16/88 1418E(cont.)

Returned 2A-A to service. 2B-B removed formaintenance.

1552E

2047E

2049E

07/17/88 0200E

Reactor at 55,percent, 600 MWe.

Returned 2B-B to service.

Began load increase.

Unit holding at 72 percent, 833 MWe. The pressurecontrol valve on the H~O injection supply line to3C heater drain tank pump failed to fully open.

0543E

0717E

1225E

Began power increase, repairs complete.

Reactor at 77 percent.

Holding for calimetric performance and.power rangeadjustment. Reactor at 90 percent, 990 MWe.

1340E

1620E

1704E

1751E

07/18/88 0300E

Adjustments complete, power ascension resumes.

Reactor at 96 percent.

Reactor at 98 percent.

Diluting the RCS to maintain 98 percent power.

Reactor at 98 percent power, llll MWe, holding becauseof high steam flow alarm initiating.

07/20/88 0800E Reactor at 98 percent power, 1122 MWe.

7/21/88 0125E Began load decrease. Received a high bus duct tempalarm.

0130E Stopped reduction. 2A bus duct cooling waterdischarge line was crimped. Corrections made andalarm cleared. Reactor at 93 percent, 1095 MWe.

0140E

0200E

0600E

Returning to 98 percent.

Reactor at 98 percent.

Reactor at 98 percent, 1120 HWe.

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SIGNIFICANT OPERATIONAL EVFNTS

Unit 2 Continued

Date Time Event

07/26/88 0141E Received high steam flow alarm on loop No. 1. Reducedturbine load. Reactor at 98 percent, 1120 HWe.

7/30/88

0800E

0030E

Reactor at 98 percent, 1120 MWe.

Began power reduction to 55 percent for repair ofspeedchanger on 2A-A main feed pump (MFP).

0320E

0610E

0815E

0842E

1230E

Reactor at 55 percent, 605 MWe.

2A-A out of service.

Maintenance begins.

2A-A returned to service.

Decision made to remove 2B-B from service formaintenance on speedchanger.

1406E

1711E

2B-B returned to service.

2A-A removed from service for maintenance onspeedchanger.

1730E

1817E

2130E

2A-A return to service.

Begin power increase.

Molding at /5 percent, 900 MWe. Oil leak on 2Acondensate booster pump.

7/31/88 0627E

0746E

Began power increase to 98 percent.

Reactor at 80 percent, 930 MWe. Oil leak on 2Aconden ate booster pump.

1045E Began load reduction to 75 percent for maintenance on2A condensate booster pump.

1119E

2400E

Reactor at 75 percent, 865 MWe.

Reactor at 75 percent, 865 MWe. Maintenance continueson ?A condensate booster pump.

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FUEL PERFORMANCE

Unit 1

The core average fuel exposure accumulated during July was 0 MMD/MTU with thetotal accumulated core average fuel exposure of 0 MMD/MTU.

Unit 2

The core average fuel exposure accumulated during July was 961.75 MWD/MTU withthe total accumulated core average fuel exposure of 9810.33 MMD/MTU.

SPENT FUEL PIT STORAGE CAPABILITIES

The total storage capability in the SFP is 1,386. Howevex', there are fivecell locations which are incapable of storing spent fuel. Four locations(A10, A11, A24, and A25) are unavailable due to a suction strainer conflict,and one location (A16) is unavailable due to an instrumentation conflict.Presently, thexe is a total of 348 "pent fuel bundles stored in the SFP.Thus, the remaining storage capacity is 1,033.

HISCELLANEOUS

Special Nuclear Material (SNH) Annual Physical Inventory

The annual physical inventox'y of all SNM (exempting Item Control Areas, ICA,whexe utilization of full pxotective clothing is required) was performed onJuly 28, 1988. The inventory was coordinated in conjunction with thesemiannual system review by Nuclear Fuel, DNE, Chattanooga. In addition,representatives from Coopers 6 Lybrand and Comptrollers Office were present.The ICAs wex'e inventoried:

ICA

New Fuel Stoxage Vault

Contents

Unit 2 (cycle 4), 80 unirxadiatedfuel assemblies.

Lead Shield Pig 15 spent incore detector tips (onlyverified tampex-indicating sealnumber).

Radiological Control Labs 4 plutonium sources

Radioactive Material Cage 21 incore flux detector1 plutonium source

There wexe no discxepancie" observed in these areas. A furthex system reviewon all SNH records is scheduled to be conducted on August 3-5, 1988.

PORVs AND SAFETY VALVES SUMMARY

No PORV" ox'afety valves were challenged in July.

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SPECIAL REPORTS

There were no special reports submitted to the NRC for the month of July.

LICENSEE EVENT REPORT S

The following licensee event x'eports (LERs) were tx'ansmitted to theNucleax'egulatoryCommission in July 1988.

LER~De"cubi t,ion of L««en'.

1-880 24 On June 15, 1988, at 1512E with unit 1 in mode 5, an unplannedreactor tx'ip signal was generated during the replacement of timerrelays associated with the RCP undervoltage (UV) relays. The timerrelays for RCP UV relays were being replaced in accordance with WP

12699 to convert the control circuit from 125V DC to 120V AC. Oneof the nineteen reactor trip signals at SQN is generated when an UVcondition is sensed on the power feeders to at least two out of thefour RCPs and the unit power is gxeater than 10 percent.Permissive P-7 unblocks "at-power" tx'ip signals when eitherpermissive P-10 or P-13 is made up. Before this event on May 25,1988, the performance of IHI-99CC10.4B, "Channel Calibration ofTurbine Impulse Pressure Channel II," was initiated. This IMIrequires that several bistables be tripped resulting in making uppermissive P-13 and subsequently permissive P-7. Deficienciesdiscovered during the performance resulted in desistance of work;however, it was agreed to allow the equipment to x'emain in thatconfiguration until performance of the IMI could be continued. OnJune 15, 1988, when the wires on the RCP UV timers weredisconnected, an UV condition was simulated causing a reactor tripsignal.

The cause of allowing WP 12699 to be performed while thiscondition, P-7, existed, resulted from an inadequate impactevaluation performed by the Woxk Control Group of plant activitiesand plant conditions for unit 1. This can be attributed to thefact that the Work Control Group is still in a learning process.To minimize the number of events caused by inadequate impactevaluations of plant conditions and plant activities, SQN hasrestructured the Work Control Group. This restructuring, shouldprovide for bettex'ontxol of work activities and awareness ofcurrent plant conditions. (p-7, -10, -13 are special conditionsthat must exist befoxe certain safety features are actuated.)

1-88025 On Juno 17, 1988, unit 1 in mode 5, two spur'ious S/G No. 3high-high level turbine txip first out annunciations werereceived. A subsequent investigation for these two events foundthat both tx'ip signals resulted from maintenance being performed onloop No. 3 S/G during testing for S/G tube leaks. The trip signalswere initiated as a xe ult of two out of three lovel txansmittersgenerating high-high level signals when the pressure was changed inthe S/G fox tube leak testing.

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LERDescxi tion of Event

1-88025(cont.)

For immediate corrective action, operators acknowledged that anactual high-high level did not occur in loop No. 3 S/G since thegenerator was drained, and it was known that it was beingpxessurized/depressuxized for tube leak testing. The bistables forthe level transmitter were tripped and the root valves opened toensure that anothex spux'ious trip signal was not generated. Forlong-tean corrective action to prevent recurrence of this eventduring S/G pressurization, TVA will add a precaution in SpecialMaintenance Instruction (SHI) 0-68-2, "Special Test — Helium LeakTesting of Steam Generator," to state that Operations will benotified that a turbine trip may occur as a result ofpressurization of the secondary side of a S/G.

1-88026 At approximately 2259E, June 29, 1988, unit 1 was in mode 5 andunit 2 at 70 percent power, all four standby D/Gs received anemergency start signal. All four D/Gs started as designed, D/G1B-B was loaded to the system. The immediate cause was anundervoltage condition on 6.9 kV shutdown board 1B-B that resultedfrom a short circuit during the performance of a MR on a breakerindicating light. The short circuit tripped feeder breaker 1722and created a loss of power condition to 6.9 Shutdown board 1B-B.The root cause of this event was unclear MR planning. Although theWR contained instructions fox'ifting the wires associated with theindicating light assembly before initiating the repair, theseinstructions wore not interpreted by the craft personnel as being arequirement. Hence, the work was initiated without lifting thewires. To prevent recurrence of this event, SQN will instruct MRplanners to ensure that each MR on an indicating light assemblythat can affect ESF equipment contains a requirement to take theappropriate action necessary to prevent a potential undervoltagecondition before work can begin. In addition to improved WRplanning, SQN will also review this event with Operations pexsonnelto ensure that they are aware of the potential problems that canarise from such routine activities as changing out indicating lamps.

1-88018Rev. 1

This revision updates the corrective action TVA has taken toprevent the recurrence of reactor trip signal generated fxom radiotransmission interference.

1-88023Rev. 1

This xevision provides additional information about four pipingsleeves for reactor coolant pump seal injection water lines thatwere discovered to be smaller than the nominal diameter shown inTVA design dxawings.

1-88027Rev, 1

This revision updates the corrective actions and more accuratelyreflects the minimum reactor coolant system average temperaturethat occurred following the reactor txip of June 6, 1988 ~

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Descri tion of Event

2-88026 On June ll, 1988, unit 2 in mode 3, Operations personnel attemptedto stroke level control valve 2-LCV-3-172 from the MCR anddiscovered that the handswitch used to manipulate the subject valvein the manual mode would not operate the valve. Instead,manipulating the handswitch for 2-LCV-3-172, (which controls AFWflow from the turbine-driven AFW pump to 3 S/G), allowed2-LCV-3-175 (which controls AFW flow from the turbine-driven AFWpump to the Ho. 4 S/G) to modulate. As a result, Operationspersonnel declared both valves inoperable and entered LCO 3.7.1.2.An investigation into this event revealed that two wires in thevalves'ontrol circuits had been crossed. It could not bedetermined the precise work activity during which this occurred;however, it was determined that this incorrect wiring configurationhad most likely been in place since at least Hovember 5, 1987.This condition was caused by the failure to comply with establishedconfiguration control requirements during the performance ofreponse time testing. SQH believes that the wires were liftedwithout being uniquely identified and, as a result, were improperlyterminated. As immediate corrective action, the wires wereconnected to their proper terminals and the valves were verified tobe operable in all possible combinations of "AUTO" and "MAHUAL"handswitch position". To prevent recurrence, SQH will review thisevent with personnel from Flectrical Maintenance (EM), InstrumentMaintenance (IM), and Modifications who may be required to liftwires associated with safety-related equipment. In addition, SQHhas reviewed the applicable configuration control procedures anddetermined that adequate guidance exists in this area for both RMand IM personnel. An enhancement to the Modifications controllingprocedure will ensure Modifications personnel have adequateguidance in this area.

2-88029 On June 19, 1988, at 0730E, unit 2 in mode 3, a CVI occurred as aresult of a spike on the particulate channel of radiation monitor2-RM-90-112. This RM provides an output to the "8" train SSPSdirectly and to the "A" train SSPS through train separationrelays. During this event, indications in the MCR were that the"A" train isolation valves had properly isolated but the "8" trainvalves had not. Subsequent to the CVI, Operations personnelverified that no high levels of radiation existed and thenproceeded to perform the necessary steps for recovery. The causeof the spurious spike could not be determined. Ho maintenance ormodification activities were being performed on unit 2 at thistime. The improper operation of a latching mechanism on a slaverelay in the SSPS was the cause of the "8" train equipmentmalfunction. As a corrective action, the latching mechanism willbe replaced/repaired.

LERDescri tion of Event

2-88030 On June'21, 1988, unit 2 in mode 2, personnel documented thepotential for a loss of required shutdown margin (SDM) following anend-of-cycle reactor trip and subsequent cooldown below the nominalno-load average RCS temperature (Tavg) of 547 degrees F. SDM

calculations performed following reactor trips have typically beenperformed approximately 30 to 50 minutes following the trip andhave been been based on either the RCS temperature at that time oron the minimum planned RCS temperature for the specific SDMsurveillance interval. As a result, these SDM calculations did notnecessarily consider the impact of the RCS cooldown immediatelyfollowing the trip.The condition was the result of a failure to identify the effectsof excessive post reactor trip cooldowns in either the core designor in plant procedures. The excessive cooldowns and subsequentaddition of positive reactivity from the negative moderatetemperature coefficient have been attributed to the overallsecondary system response to a reactor trip. SQN, in conjunctionwith Westinghouse, has back-calculated the minimum SDM during pastoperation and verified the requirements have been satisfied at alltimes during cycle 3 operation of units 1 and 2.

As immediate corrective action, SQN revised the emergencyinstruction used to guide operator action following a reactor tripto include a provision requiring plant operators to manuallycontrol flow if the RCS cooldowns become excessive. If the plantcooldown continues, operators are instructed to borate the RCS tomaintain adequate SDM. SQN is currently formulating theappropriate long-term corrective actions and will submit asupplement to this report t.v proved details of these actions.

2-88013Rev. 1

This revision provides additional information regarding (1) aninvestigation into the cause of the first reactor trip and (2) thecorrective action TVA has taken to prevent recurrence of theseevents.

2-88022Rev. 1

This revision provides updated details on the completion date oftraining for Instrument Maintenance personnel.

2-88023Rev. 1

This revision updates the corrective action section of thisreport.

2-88027Rev. 1

This revision updates the corrective actions and reflects moreaccurately the minimum reactor coolant system average temperaturethat occurred following the reactor trip of Juno 6, 1988.

-8-

ABBREVIATIONSPage 1 of 2

1. ABGTS2. ABSCE3. ABI4. AFW

5. AOI6. ASOS7. AUO

8. BAT9. BIT

10. CAQR11. CCP12. CCW

13. CRI14. CREVS15. CSS(CS)16. CVI17. D/G(s)18. DCR19. DNE20. ECCS21. ECN22. EGTS23. EMI24 EQ

25. ERCW

26. ESF(A)27. FCV28. FSAR29. FWI30. GOI31. GPM32. HO

33. IM34. IMI35. LCV36. LCO

Auxiliary Building Gas Treatment SystemAuxiliary Building Secondary Containment FnclosureAuxili.ary Building IsolationAuxiliary FeedwaterAbnormal Operating InstructionAssistant Shift Operation SupervisorAssistant Unit OperatorBoric Acid Storage TankBoron Injection TankCondition Adverse To Quali.ty ReportCentrifugal Charging PumpComponent Cooling WaterControl Room IsolationControl Room Emergency Venti.lation SystemContainment Spray SystemContainment Ventilation IsolationDiesel Generator(s)Design Change RequestDivision of Nuclear EngineeringEmergency Core Cooling SystemEngineering Change NoticeEmergency Gas Treatment SystemElectromagnetic InterferenceEnvironmentally Qua lified/EnvironmentalQualificationFssential Raw Cooling WaterEngineered Safety Feature (Actuation)Flow Control ValveFinal Safety Analysis ReportFeedwater IsolationGeneral Operating T~structionGallons Per MinuteHold OrderInstrument MechanicInstrument Maintenance InstructionLevel Control ValveLimiting Condition for Operation

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ABBREVIATIONSPage 2 of 2

37. LOCA38. MAST39. MYI40. MFP41. MOV

42. MSI43. MSIV44. MCR

45. NSS46. NSSS47. PORC

48. PRO

49. RCS50. RHR51. RM

52. RWST

53. SCR54. SFP55. S/G(s)56. SI57. SMI58. SOI59. SQN60. SR61. SSPS62. TACF63. TI64. TS(s)65. UO/(S)RO66. WP

67. WR

Loss OE Coolant AccidentMaximum Allowable Stroke TimeMain Feedwater IsolationMain Feedwater PumpMotor Operated ValveMain Steam IsolationMain Steam Isolation ValveMain Control RoomNuclear Security ServiceNuclear Steam Supply SystemPlant Operati.on Review CommitteePotential Reportable OccurrenceReactor Coolant SystemResi.dual Heat RemovalRadiation Monitor (RAD Monitor/RAD MON)Refueling Water Storage TankSignificant Condition ReportSpent Fuel PitSteam Generator(s)Surveillance Instruction/or Safety InjectionSpecial Maintenance InstructionSystem Operating Instructi.onSequoyah Nuclear PlantSurveillance RequirementSolid State Pr'otection SystemTemporary Alteration Control FormTechnical InstructionTechnical Specification(s)Unit Operator/(Senior) Reactor OperatorWorkplanWork Request

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RADWASTE SUMMARY

July 1988

1. Total volume'f solid waste shipped offsite:

A. Dry active waste: 828 ft.~ Activity: 9.4026 curies

B. Spent resins, sludges, bottoms: 0Activity: N/A curies

Shipped: July 4, 1988 Barnwell, Inc.

2. Radwasto onsite and awaiting shipment:

A. Resin in storage: 109 ft.~

B. Estimate resin that will be generated: 109 ft.a

C. Dry active waste awaiting, shipment: 667.5 ft.~

OFFSITE DOSE CALCULATION MANUAL CHANGES

No changes werc made to the SQN Offsite Dose Calculation Manual (ODCM)in July 1988.

OPERATING STATISTICS(NRC REPORTS)

~ '

DQCI(I:T NO. 50-32 iDA'I'E AUGU" T 05, 1988COt'1PLETED OY D. C.

DUPRI.I'ELEPHOhlE

( 6 1 5 > 870-67" i'

~

7.8.

IT NAME: BEGUQYAH NUCLEAR PL*MT> UN I TR=.PORT PERIOD: JULY 198;S

:CENSED THERi1AL POWER (ilWT'411. 0"l'-'MEPLATE RATING (GROSS I'IWi:); 1220. 6I''FBI GIV ELFCTR ICAL RATING ("I(.:T l1WE): 1148. 0"l~X IilUh1 DEPENDABLE CAPACITY (GROSS Ml'c ): 1183. 0!"(iXIiIUM DEPENDABLE CAPACITY (NET MW- ): 1 l(18. 0:F CHANGES OCCUR IN CAPACI ( Y RATINGS( ITEMS NUI1BFRS:( TIIROUGH ')SINCE LAST REP"I.: IVE REASONS:

NOTES;

P('WER LEVEL TO WHICI-I RESTR ICTED, IF ANY(NE I MWE):

10. REASONS FOR RESTRICTIONS) IF ANY:

Tl-IIS t1QNTH YR. -TQ-DATF CUiilULATIVE

11.12.

13 ~

17.18.19.20.21.22.23.24 ~

'".OURS IN REPORTING PERIODIVUMBER QF HOURS RFACTQR WAS CRITICAL

REACTOR RESERVE SHUTDQWIV I{OURS11("URS (-'El'IERA'COR QiN-LINFUNIT RESERVE SHUTDOWN HOURS'-'ROSS IHERMAL ENERGY GEN-RATED (t1WH)GROSS ELECTP, ICAL FNERGY GEN. ( MWH )NET FLECTRICAL ENERGY GENERATED (MWH)U',wl T SERVI CE FACTOP.UNIT AVAILABILITYFACTORUNIT CAP*C I TY FACTOR (USING t1DC IVET)UNIT CAP AC I TY FACTOR ( US I IVG DER NET >

UiNIT FORCED QUTAGF RATFSl UTDOWNS SCHEDULED OVEP. IVEX1 6 MONTHS

744. OO0 QO

0. 00n. Qn0. 000. 00Q. 00

-3766. 000 000. 000. QQ0. no

i QQ Qn(TYPES'ATEi

5111. 00 62112. 000. 00 24444. 91

0. 00 0. 000. 00 23781. 13O. OO 0. 000. 00 77060971. 910. 00 25976386. 00

-34053. OO 2ne20270. 000. 00 38. 290. 00 38. 290. 00 34. 810. 00 34. 81

100. 00 55. 27AND DURATION Ql= EACH>:

25. I.'HUTDOWN AT END QF REPORT I ER IOD ESTIMATED DATE OF STARl UP:~ Tl"'E R EST*RE OF UIVI T—1 IS TLNTATIVELY SCHEDULED FOR SEP TEI1BER 1 988

NOT:-. IHAT THF- THE YR- -TO-DATE ANDCUhIUI.(lTIVE VALUFS HAVE DEEIP UPDATFD.

-12-

SEQUOYAH NUCLEAR PLANTAVERAGE DAILY POWER LEVEL

DOCKET NO. : 50-327UNIT : ONEDATE : AUGUST 05,1988

COMPLETED BY - D C DUPREETELEPHONE - (615)870-6722

MONTH: JULY 1988

AVERAGE DAILY POWER LEVELDAY (MWe Net)

01

02

03

04

05

06

07

08

09

10

12

13

15

16

DAY

17

19

20

21

22

23

24

25

27

28

29

30

31

AVERAGE DAILY POWER LEVEL(MWe Net)

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UNIT SIIUTDORlS AND POWER REDUCTIONS

REPORT tlONTII JULY 1988

DOCKET NO. 50-327UNIT NAHE Se uovah One

DATE Au ust 5 1988COMPLETED BY D. C. Dupree

TELEPIIONE 615 870-6722

No. DateC ~o N

LI0

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C ICoEO

C)

'4w o0 CC Ll

V'0 'r4 cg0 4J C'J

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LicenseeEvent

Report 8

6<Q 0Ulh 0M

Cannr. e0 'U0- o6 O0(J

Cause & CorrectiveAction to

Prevent Recurrence

880101 744 F 4 Design Control, Configuration Updating, andEmployee Concerns.

F: ForcedS: Schcdulcd

2Heason:A-Equipmcnt Failure (Fxplain)B-Ilaintenance or TestC-RefuelingD-Regulatory RestrictionE-Operator Training 6 Liccnsc ExaminationF-AdministrativeG-Operational Error (Explain)II-Other (Explain)

aHethod:I-llanual2-lfanual Scram.3-Automatic Scram.4-Cont. of Existing

Outage5-Reduction9-Other .

"Exhibit G-Inst.ructionsfor Preparation of DataFntry Sheets for LicenseeEvent Report (LER) File(NlJREG-0161)

Exhibit I-Same Source

i i" i(t i T I I'l(r ~ TATUS

!)I.l(:fiE 1 i~lQ. aa-3?8DA'fE AUGUS! Ooi 1988COI'1P LE TED 0 Y D C ~ DUP!'Il.l.TE! EPI-IQiiIE (615) 870-67''2

I~ ~

6.7.S.

~ "T I'IAI'lE: SEGUOYAH NUCLEAR ".. ' I UiVI T 2"-PQR T PER 'QD ~ULY '1988:C~:NSED THI.RMAL POWER (i!!IT i 24 l l. 0'- MLP LATE RATING ( GR QSS !'N: i 1

" 20. 6~ 6'8'ivk ELECTR ICAL RATING <i i i 'NE): I 1 +8 0'c'X IMUii <) 'NDADLE Cc'i!tACIT s ~ 0" ikSS l1(IE): 1 183. 0',AX IMUM DEPENDABLE CAPAC I . Y NE l !AWE): f 148. <):;" CHANGES QCCUP. IN CAPACITY f(*TINGS< ITEMS NUMDERS

THR OUGH 7 ) S I i lC LAST REP s ' ' VE

REASGs'IS.'QTLS:

I'Wi=R LEVEL TO WHICH RESTR1CTEDi IF ANY(I'JFT i1WE):

10. iREASQNS FOR RESTRICT IQNSi IF ANY:

TH IS MQNTiH ~ YR- -TO-DATE C(II'IUL*lIVE

11.12 ~

13.14.

5.

7.18.19 ~

20.21.I" i ~

23 0

2 J.

! .'OURS IN REPORTING PERIOD 744. nn 5 1 1 1. Oo 54072. 00I'Ji.:M!3ER OF HOURS REACTOR WAS CR I 7 ICAL 744. 00 1529. 10 23513. 64RI."ACTOR RESERVE SHUTDOWN HOURS 0. 00 o. oa o. ooi iI 'URS GENE..ATQR QN-LIiVE 744. 00 l 424. 75 22918. 97

RVE SHIJTDQWN HOURS 0. 00 0. 00 o. 00.-.'i oss THER!'1AL '-",i'!FRGY GFNERATED ( !NH) 2050019. 28 3650995. 64 72/78972. 86

ROSS ELFCTR ICAL ENFRGY GEiJ. <MWH) 683010. 00 1197940. 00 2/1734720. 00~IET =LFC I P I C(4L El'JEPGY ('Ei JEPATED ( MWH ) 655061 ~ 00 1072087 00 23'80232. 00UNI T SERV.'CE k iACTQA 100. 00 27. 88 42. 39UfiJI T AV*ILAGILI TY 1 i'CTOR 100. 00 27. 88 42. 39I 'blI T CAPAC I'1 Y FACTOR (USIi~lG I'1DC NE'"') 76. 6"/ l8. 27 37. 99ui':1T CArACIrY FACTOR(USIfl( DEB NET) 76. *9 18. 27 37. 99U!,IT FORCED OUTAGE fiATF o. aa 72. 12 53. 39.:-'I"U 'O(liJS SCl'!EDULED OVER f "'.:. 3 6 MONTHS ( 1 YPE DATE AND DURATION'3!'ACH):

=O'R REFUE',"I QU CAGE;8 TE!'ITAT!V!=LY SCHEDULFD FQR JANUARY I /O /iITH A DURATION OF 65 DA. 8,

'/ S."iU f'DOWN ' l. I'JD QF REPORT PER IOD EST I MATED DATE OF STARTUP:

NOT- THAT THE THE YR. -TQ-DATE ANDCUMULATIV VALUFS HAVE i)Ett'I UPDATED

-15"

SEQUOYAH NUCLEAR PLANTAVERAGE DAILY POWER LEVEL

DOCKET NO.: 50-328UNIT: TWODATE : AUGUST 05,1988

COMPLETED BY D C DUPREETELEPHONE : (615)870-6722

MONTH: JULY 1988

AVERAGE DAILY POWER LEVELDAY (MWe Net) DAY

AVERAGE DAILY POWER LEVEL(MWe Net)

01

02

03

04

05

06

07

08

09

10

12

15

752

756

756

757

755

755

754

857

758

757

758

757

758

756

757

622

17

18

19

20

21

23

26

27

29

30

31

928

1069

1068

1079

1082

1081

1078

1078

1079

1081

1078

1076

1078

666

846

UNIT SNUTDORlS AND PO'4ER REDUCTIONS

REPORT NOHTlj JULY 1988

DOCKET NO. 50-328UNIT NAtiE Sequoyah Two

DATE August 1, 1988

CotlPLETED BV D. G DupreeTELEPllOHE

Ho. DateC ~0 Ol

~rtIJcS 0

A

CV

0VlrqCI

w 00 CO IJ

0CO

0 IJ IJIJ g

IJIJ

0

LicenseeEvent

Rcport JI

F.mCl 0IJUl 0NO

CA

IJCIJinr. e0 00 0

O0

Cause & CorrectiveAction to

Prevent Recurrence

10 880716 S 0 B Maintenance performed on the speedchanger ofboth main feedwater pumps.

880730 S 0 Maintenance on 2A-A main fecdwater pumpspeedchanger.

iF: ForcedS: Scheduled

2Reason:A-Equipmcnt Failure (Explain)8-Maintenance or TestC-RefuelingD-Regulatory RestrictionE-Operator Trai»inl; & Liccnsc ExaminationF-AIlminist ra tiveG-Operational Error (Explain)ll-0thcr (Explain)

atlethod:1-tlanua l2-tlanual Scram.3-Automatic Scram.4-Cont. of Existing

Outage5-Reduction9-Other

"Exhibit G-Instructionsfor Preparation of DataEntry Sheets for LicenseeEv. n t Rcpo rt (LER) File(tH!REG" 0161)

sExhibit I-Same Source

OPERATING STATISTICS(TVA REPORTS)

r VA 1 382A IONP 4 88) NUCLEAR PLANT OPERAT/NG STATISTICS

SEOUOYAH NUCLEAR Plant

ItemNo. Unit No. UNIT OiVE

Month JUI.Y

UNIT TWO

1988

PLAViT

Co

1 Avera e Houri Gioss Load kW

2 Maximum Hour Nct Generation MWh

3 Core Thermal Enera Gen GWO I 2

Steam Gcn. 1'hci'mal Lncr Gcn., GWO

5 Gross Electrical Gen. MWh

6 Station Use. MWh

7 Net Electrical Gen., MWh

8 Station Use. Percent

9 Accum. Core Avq. Exposure. MWD/Ton10 CTEG This Month. 10 BTU

11 SGTEG This Month. 10 BTU12

13 Hours Aeactor Was Critical14 Unit Use Hours Min.

15 Ca acit Factor, Percent

16 Tiirbine Avail. Factor Percciit7 Gnr rAvail Fator Prcnl

18 Tiiibo en. Avail. Factor PercentAn r Av I F r P r n

20 Unit Avail. Factor Percent

Tiirhine StartuAeart i Cold tart«

0

000

3,766-3,766

N A000

0.00.000.00.00.00.00.00.000

918,0241,088

85.417585.8766

683,01027,949

655,0614.099,810

6,996,7167i030%226

744.P744:00100.0100.0100.0100. 0100. 0100. 0

00

918,0241, 088

85.417 c

85 ~ 8266683,010

31,715651,295

4.649,810

6,996,7167,030,226

744. P

744: 0050.050. 050. 050. 050. 050. 0

00

~II

CP

Q.

oI

24 Gross Heat Aatc. 13tu/kWh

25 Nel Heat Aatc. Atu/kWhGross Heat Rate Btu kWh w o oilNet Heat Rate Btu ktA w o oil

28 Throttle Pressure, psirI

29 Throttle Tem cratiire, F

30 Exhaust Piessure. tnt lit Abs.

31 Intake Waler Tcmo.. 'F3233 Main Feedwater. M Ib/hr34

35

36

37 Full Power Capacit, EFPO

38 Accum. Cycle Full Power Days. EFPD

39 Oil Fired for Generation. Gallons

40 Oil Hea in Value'tu Gal.

~ nr inMWh

N/A

N/AN AN/AN A

N A

404.860.0

10,24010,680

850.3525.9

2. 9175.8

11. 9

363.65255.4399

10,24010,74010,24010 740850.3529.9

2.975.8

11. 9

768.51255.4399

1,386138,000

21

Max. Hour Net Gcn.

MWh Time Date

43 1,088 1500 7/20/88

Max. Oay Net Gen.MWh Date

25,956 7/21/88

LoadFactor. %

80.46

Co

Aernarks: IF'r f3FNP this value is MWO/STU and lor SQNP and WI3NP this value is MWD/MTU.

2(t) indicates Thermal Energy.

V GE ANO AVAILABILITY

Litcn5cd Reactor Power 34TT h1W(th)

Generator Retina TZ 0 ~ 5 trtV(tc)

Dccg 0 ccElhccic Iilcl g I~Decl'I

SE UOYAH

unit NO. O'IE

Nut tear Plnnt

I Iggg<llr/Ye w JULY I 988

Pc<coil t tnglg~ 1C<

Osy

Time Unl< Avolloblc

Tel<< acn. r<nt <<<cd

Hr< h'Icn In< Mcn III< Min

fHIIC r<u< Ag<c<D<2<C

Tug nlni Ccn. nevi<or Unc I

24 '00 24 '00 24 200 24 < 0024 0024 <0024 too24 00

24 Iaa 24~0024 Lao 24 loo24 < 00

I24<

00~24 00

24 lao24~0024 ioo

24 ioo 2C '0024 <002C 200

24 <0024 00

24 'OO 20 DD 24 <0024 00zC <oo zC Ioa zc Ioo 24 oo

'Time

Ou<

I<i< h<in

TuneIn

< <ii hie n

Our AGE CAu5E

OestEn Controt ~Conf Ipurst ionUfgdntfnE~ nnd EPp)oyltE CoyccL

UNI f'5IATU5f)URII:hiOufr GE

I.<ET IIOO OF5IIUTTING

OOIYNREACTOR

~NA ~cdC CX

CIIIIIICCf IVE AC I IONIAKCII TO PIIEVI.IIT

RLPEIITIO I

IO

lzl3

15

~24 00~24 0024 <0024

<00

24 '0024 0024 <00

24 '0024~ 0024 <0024 '0024~ 00

I24 0024 <00

22 002C IQO24 <00

2C DD

z«ao24 '00~24 00

24 i 0024 0024 002< Ioo24 Ioa2C~ OQ

2C 00I

c

, rnl

'1I'

c

j,

17lsl9

?'I

?223

2526272829303l

24 00 24 0024 iao24 '0024 0024 '00

24 <0024 0024 <0024 ~00

24 I 002C '0024 ~oo 24~ 00

~20 024 <QQ

24 002~4002C '00 24 I 00

24 00zzlt)2 ! 0

~24 00

24 00 24 OQ 24 OQ

2 go

22602 <00

24 0024 0024 00 24 I 00 24 '00

144 I 00 144 00 44 <00 144 00

24 00 24 <00 ~24 00 24 I 0024 lao 24 00 24 iao 24 0024 00 24 00 24 00 24 0024 <00 24 <00 24 00 24 0024 <00 24 00 24 gaa 24 I 002 00 24 00 24 00 24 I 0024 < 00 24 Iao 24 200 24 00

70 c - -rr 2 Dh

v-

. 's

fI VAribCOU II'IvJ /4)

8EQUOYAH Nuclear Plnnt

UNI E ANO AVAILABILITY

,i .

i

.i

.1Tinic Unit Avoilcblc

To los Ccn. NOI USCu TurhinC

Ooy HrS hsin2 IIIO

Ins Min Iris Min Isrs Min

4 I

Licensed ftcoctor Power 3411 MW(th)

Generator Acting 1220-5 MW(e)

Design Gross Electrical Anting 1183 MW

Tlnle IIOI Avaucbfe

VnilACCCIOrCcn.

IOS IAn Isis hun Ins Min

Unit No. Tt'0

Unit

Tonic

InT insc

OUI

Isis hbn Isis lAin

OU fhGE CAUSE

MCT IIOO OFSIIUTT ING

OOWNACACTOIT

UNI fSTATUSOUITINCOUIAGC

COIIAECTIVCACTIONTAKCN fOPACVENT

flCPC f I T ION

h1rsnth/Ycor JULY 1988

r cr rod tins s

~ISO24 Io

24 00

2g s09g4 loo

24 00

IIVO

I

II

10

1213I415161718

021

2223

252627

293031

Total

24 Ioo24 '0024 0

4 Io24 lo24 0024 0

4 024 Ioo24 loo24 0024 0024 0024 0024 Ioo24 1 0024 0024 0024 Ioo

744 IOO

4 I 024 00

4 004 00

4 04 004 0

24 00C Io4 0

24 0024 0024 lop24 0024 002C Ioo24 0024 Ioo24 Ioo24 0024 too44 00

~ I

~C OC ~W

REACTOR HISTOGRAMSEQUOYAH UNlT ONE

I—

OQ

Q

Q

OCL

QOI—O<C

Q

100

90

80

70

60

50

40

30

20

'l0

0Unit in mode f5

13 17JULY 1988

21. 25 29

REACTOR HISTOGRAMSEQUOYAH UNIT TWO

OEL

CL

Cr

OCL

OI—C3

Q

100

90

80

70

60

50

40

30

20

10

0

2 3

6 6A

6

13 17

JULY 1988

21. 25 29

1. Hold for core life ext.ension.

2. Load reduction. Maintenance on the speedchanger on both 2A-A and 2B-Bmain feed pump.

3. The pressure control valve on the H~O injection supply line failedto properly open, stopped power ascension.

4 ~ Reactor at 98 percent power. High steam flow alarm comes in at powergreater than 98 percent.

5. 2A bus duct alarm initiated. Power was reduced.

6. Hold for oil leak on 2A condensate booster pump.

6A Reduced load to repair condensate booster pump.

-23-

SUMMARY OF MAINTENANCE ACTIVITIES

HAINTENANCE SUHMARY(ELECTRICAL)

'hl

ELWRICAL HAIHTEHAHCE tlGHntLY SUttttARY

CDHP

tJt2 .... U FUHC SYS ADDRESS. DATE.... DESCRIPTIDH

08-05-88

CORRECTIVE ACTINi.

74 2 s"iVOP 067

BPI2306 1 RATf: 082

8751406 2 llTRf'30

0103 01/11/88 2-ttUQP-067-0103-BiE>HPRO>i >10CFR50.4't~3.

STROKED VALVE FOR SI-166.3 STROKE TIllEMAS 63.7 SEC ttAXIttUtt ALLOMAf'LE IS 60.0SEC.

Ul: 03/10/88 I-RATR-082-LB-AiCuHPRD>3)REMDRK

CDHHECTIGHS RETMEEH CELLS 12 ! 13 AHD

CELLS 21 8 22 PEP. llI-10.54. CELLS

CDHHECTIOH CH 12 8 13 IS Af'DUE 207. CF

RASE UALUE. TECH SPEC IS HOT IHVDLUED.

REF SI-238 PERFGRllED 12-14-87

01'ld 06/13/88 2-ttTRB-030-01'td-h,c~locFR50.4 t~.@PRO~3,

ROOtt COOLER tIKIH6 A LGT QF HQISE.

IHVESTICATE REARIH6 AHO REPAIR

REtlQTE STROKE TlttE MAS 63.7 SECTS.ttAXIttUtt ALLOMABLE TIttE IS 60.0 SECOHOS.

ADJUSTEO ttECHAHICAL STOPS AHO LIHITS.PERFURtKD ttOTDR OPERATED VALUE

AHALYTESTIH6. MR R274174

THE IHTERCELl CGHHECTGR "Z-M"MAS RAO

POSSIBLY OUE TO lEAD OXIDE f'UILDUP.REMD"KED CGHHECTIGHS BETMEEH CELLS 12

13'1 AHD 22. REPLACIH6 2 BARSt f'DLTS

PJlD HUTS. MR 82'l2306. RBUESTED 'lHAT A

FAIlURE AHALYSIS BE PERFOPJlED BY THE

ttAIHTEHAHCE EHOIHEERIH6 SECTIQH.

THE BELT TEHSIOH MAS TOG TINT RESULTIH6

IH BAD REARIH6S AHD PEHT Sl!AFT.

REFEREHCE MR B75143'l FDR f'EARIH6

REPlACalEHTS. REPLACED THE tlQTCtf.

VEPJFIED ACTUAL NIDOR RPHS MAS 1764.REIHSTALLEO llDTOR PULLEY AHD ALI6HED.

FAH SPEED=1522 RPttS AHD ttIHItlUtt=1583.MHEH ttQTOR MAS RAHU THE BEARIH6S StlCKED

AHD SLUH6 CREASE.

-24-

MAINTENANCE SUMMARY(INSTRUMENTATION)

0

f

INfRUttM HAIHTEHAHCE tlCHTHLY SUttttARY 08-05-88COUP

N2.... U FUHC SYS ADDRESS. DATE.... DESCRIPTIOH. .......... CORRECTIVE ACTIOH.

3 2 LT 063 0178 06/06/88 2-LT-063-0178-F>DURIHC PERFORMHCE OF Ptl

1653-063'OUHD T.P. READIHQ OUT GF

TOLERAHCE.

8751342 2 TR 070 0161 Od/16/88 2-TR-070-0161-iE<HPRD>3iTR DOES HOT

ROTATE. REPAIR GR REPLACE

8293686 2 LT 068 '338 05/12/88 2-LT-068-0339-D,VEHT COHDEHSATE POT TO

DETERtlIHE ZF SEHSE LIHE IS BLOCKED

THE TRAHSt)ITTER MAS GUT OF TOLERAHCE

HI6H TtlROUNOUT THE EHTIME RAHCE. HO

ROOT CAUSE DETERtlIHED. TIIE TRAHStlITTER

MAS RECALIBRATED TO DESIRED TQLERAHCE

AHD RETURHED TO SERVICE. (MR48264123)

THE TRAHStlITTER HAD A LOSS ar HEAD DUE

TO A DEHT PRESSURIZER TAP. VEHTED

CGNKHSATE HEAD POT PER IN-Xld. RECALEO

AHD CAQDRATED TRAHStlITTER PER

ICFI88<7'ld AHD It!I"'llCC5.428.PERFORI'ZD PllT AKD RETUPZED TO SERVICE.

(MRIB2't3686)

THE GEARS IHSIDE THE MTOR DRIVE

ASSEtlBLY MERE FGUHD TO 8E STRIPPED. $marCAUSE GF STRIPPED GEARS IS LCHGMH. THE

CHART DRIVE ASSEMBLY MAS REPLACED AHD

THE PllT MAS PERFORMED AHD SATISFIED.

VERIFIED THAT CHARASSEtt8LY MAS ROTATIHG

PROPERLY. (MRi8751342)

-25-

IHSTRUiscMT NAIHTEHAHCE lfO'lTllLY SU1NARY 08<5-88CGllF

AR2 U FUHC SYS ADDRESS. DA1E.... DESCRIP1IDH ....... CDPRECTIVE ACTIOH...

80031 2 LCV 002 0003 07/01/88 2-LCV-002-0003-) NI1H THE COHTROLLER IH!5AHUAL (> 60%) THE FLOW SWIHCS FHN 31%

TO 55%. LDCALLY AT THE L':oLVEi TUE VALVE

STEll IS SWIHCIHC. IHVESTICATE AIREFATR

NISSIRC FEEDDACK CLIF, OSCILLATIOH

CAUSIN VIDRATIGH FEEDRACKi WEAR AHD

ACE. REPLACED PRESURE RECULATOR. VALVE

POSITIGHEH PRESSNE IHDICATORS.

IHSTALLED FEEDPACK ARH CLIP VERIFIED

VALVE S1RQKE AND RETURHED VALVE TO

HORUAL GPERATIUH. <WR5 878)031)

-26-

MAINTENANCE SUMMARY{MECHANICAL)

0

0

p

llECHAHICAL MIHTEHAHCE llQHTHLY SlNQARY 08-05-88COHP

HR2.... U FUHC SYS ADDRESS. DATE.... DESCRIPTIOX. CORRECTIVE ACTIQH.

'253&9 2 FCV 087

f'264046 2 FCV 070

f'78085'l 1 VLV 070

0021 07/23/88 2-FCV-087-0021-DiREPLACE HITRQCEH

BLADDER AHD/OR SCHRADER VLV ASSOCIATED

MITH HYDRAULIC ACCLtH OM alHI ISOL VLV

0133 01/1 l/88 2-FCV-070-0133.haE>P2N3i THERNL MRIERCGHTAIHnEHT ISOLATIOH FCV-0?0-133 HAS OH

EXCESSIVE PACKIMG LEAK <DUE TO THIS

STATUS FILEOM OF/25/88 1-VLV-070-076-hiVALVE HAS LEAK NDY

CASKET LEAK Ae PACKIHC

DEf'ECTIVE STE!l IH SCHRADER VALVE.

REPLACED STEll IH SCHRADER VALVE AHD

RETURHED TG SERVICE. <IlR8 P2536N)PACKIHG HAS LOOSE. THEPE HAS HO

ADJUSTllEHT LEFT. DISASSEHf'LED

VALVEiREPACKED AHD REASSEHf'LED VALVE.

<MRS B2A048)VALVE HAS IHSTALLED NETHiOUT PACKIHC,

IHSTALLED CRAPHITE TAPE QH CASKET AMD

PACKED VALVE. RETNHED TQ SERVICE. <NRI

87803 Pl)

-27"

00'l0 Od/25/88 2-FCV-070-00'tO-A)E~HPRDN.N10CFR50.4'le.1HSPECT PACKIHC ADJUST AHD/OR REPLACE AS

REttUIRED

TQtt3826 1 FCU 070 0133 07/07/88 1-FCU-070-0133-A, EwHP RDa3, PER

SOI-70.1h-l 1-70-786 SHDULD DE OKH) DUT

THE ULV IS COMFIGURED CLDSED DUE VLV

STOI LEAK DFF FROll 1-FCU-70-133.

8768706 2 LCU 003 0156 07/02/88 2-LCV-003-0156-A)VALVE EXCEEDED ltAST

DURIHG SI-166.1. IHVESTIGATE AHD REPAIRAS NECESSARY.

rEC:IAHTQL tthIHTEHAHCE MHTHLY SUtttthRY 08-05-88COltP

rR2.... U FMC SYS ADDRESS. DATE.... DESCRIPTIOH.

E'232760 2 FCV 070

CORRECTIUE ACTIOH.

VALVE IHTERHALS 1KRE RUSTFD. LAHTEFH

RING STUCK HOT ALLDNIHG PROPER PACKIHG

OF VALVE. REASSEtt8LED AHD REPACKED

VALVF.. RETURHED VALVE TO SERVICE.

(NPTtt232760)

PACKTHG HAD HQ tiORE ADJUSTttEHT LEFT.COHTIHUED LEAKAGE tthY HAVE AFFECTED

REACTDR CODLAHT KlP THERtQL DARRIER

OPERATIIB. IHSTALLED HEN PACKIHG AHD HEN

8OHHET GASKET AHD RETURHED TO SERVICE.(NFT82<Lt826)

HDLE NAS FOUHD IH DIAPHRAGtt. IHSTALLED

HEN DIAPHRAGll AHD PERFOtUtED SI-166.1 AHD

VALVE PASSED THE TIllE LIllIT.(NPRc768706)

-28-

0

MECHANICAL MAINTENANCE MONTHfY REPORT FOR JULY 1988

COMMON

1. Replaced diaphragm on 0-FCV-014-0300 (Condensate System).

2. Completed repair on ERCW traveling screen O-SCR-067-0475.

Unit 1

1. Completed various activities on the ice condenser system and relatedcomponents.

2. Completed work on steam generators.

3. Completed work on several valves on the RCS system.

4. Completed repair on "BB" ERCW traveling screen 1-SCR-067-0475.

5. Functional testing on snubbers.

6. Installed new diaphragms on several Grinnel valves.

7. Completed repair on limitorque operator on 1-MVOP-002-0003.

8. Completed repair on unit 1 polar crane.

9. Installed new lower seal housing bolts on RCP l74.

10. Repairing throttle valves.

ll. Rebuilt several valves on system 63 (Safety Injection).

12. Completed repairing and testing containment personnel airlocks.

13. Rebuilt pressurizer safety valves.

14, Completed work on long cycle valves.

15. Installed new solenoid on 1-FSV-062-0022 (Chemical Volume and Control,~ IPVCSe ~ )

16. Completed work on several valves on the CYCS system.

17. Completed several WRs on the glycol system.

"29-

4

MECHANICAL MAINTENANCE MONTHLY REPORT FOR JULY 1988

Unit 2

1. Completed work on CCW traveling screens.

2. Completed monthly/annual inspection on D/G 2A-A.

3. Completed repair on 2A-A boric acid transfer pump.

4. Completed repair on hanger 2-HGR-081.

5. Installed new valve at 2-HCV-035-0557 (Generator Cooling System) .

6. Repairing main feed pump.

7. Repairing amertap system.

8. Completed testing containment personnel airlocks.

9. Completed repair on generator bus duct cooler fan.

10. Installed new valve at 2-HCV-027-0732, (Condenser Circulating Water).

Other

Continued closure of various CAQRs, CARs, DRs, etc.

"30-

MAINTENANCE SUMMARY(MODIFICATIONS}

SUHHARY OF CWORK COHPLETED

HODIFICATIONS - CURRENT STATUS

JULY 1988

P

0

Ma'or Ca ital Pro'ects:

PH7102: ECH 5958 — Re lace Peedwater Heaters 5 and 4

No work in progress at this time.

PH7105: ECH 5009 — E"sential Raw Coolin Water ERCW Pi inChan cput From Carbon Steel to Stainless Steel

No additional pipe replacement is scheduled in the ne..rfuture.

PH7108: ECH 6720 — Crane Consistenc Pro ram

Unit 1 polar crane blocks and limit switch weights remain tobe painted.

Unit 2 polar crane post modification testing by ElectricalMaintenance is not complete.

Auxiliary Building crane (WP 12569) has completed reviewcycle. Turbine Building 200 ton cranes (Unit 1/6720-04, Unit2/6720-03) are currently in Plant Manager's office forapproval. Turbine Building 15 ton crane workplans (Unit1/6720-06, Unit 2/6720-05) and 5 ton Service Building crane(6702-02) workplan are in the process of being written.

Modification of Turbine Building unit 2, 200 ton crane isscheduled to start August 15, 1988.

PN7115: ECN 6719 — Volumetric Intrusion Detection S stem

ECN 6719 is in work. Design is working on making the systemfunctional. Lighting is not finished. Field Change Request(FCR) 6645 for DNE changes is approved. Work is proceeding.

PN7122: DCR 1373 Secondar Side

No work in progress at this time.

ECN 5841 — Mot Sho Fire Protection/Evacuation Alarm—WP 12637

All fieldwork for evacuation alarm is complete. AwaitingWork Request (MR) B240406 to be worked to restart fans to dofunctional test on fire protection.

-31-

4

Ma'or Ca ital Pro'ects cont.

PN713D: DCR 1156 — Poet Acrident Nonitorin

This work is now scheduled for unit 1 cycle 4 (U1C4) and unit2 by unit 2 cycle 4 (U2C4).

PN7132: DCN DD26 — Sewn e To*atnent Paoilit and Civil D vade

Work has begun.

PN7136: ECN 6259 — MSR Tube Bundle Re lacement

ECN is complete except for PMT and inservice leak test. Leakchecks will be performed during system heatup. Unit 2 leakchecks are complete.

PN7161: ECN 5855 — Re lacement of Doors A56 and A57

WP 11654 is complete.

PN7181: DCR 1898 — ECNs 6832 and 6596 — Dr Active Waste DAW

D~oildin

Electrical interface work is complete. Workplan closure heldfor Electrical Maintenance (WP 12478), checks and update ofSOIs by Operations, and Operations (WP 12477) pending RHSI-1revision.

Si nificant Items:

PN7199: Miscellaneous Activities Under 100 090

This was for various work orders prepared for work under4100,000 total site cost. This work was done as manpowerresources were available.

-32-

Other Items:

ECN 5111 — Provide Permanent Power to Manholes 42-46

FCR 4572R2 has been written to supersede 4572R1 for conduit and cablerouting for manholes 42-46. An instruction change form is beingwritten to revise MP 12262 to incorporate latest design information onFCR 4572R2.

ECN 5503 — Evacuation Alarms 0&PS/Fire Detection 0&PS

Mork stopped for lack of funding.

ECN 5552 — Condensate Demineralizer Modifications and High Crud Filter

Upgrade to higher range instrumentation for condensate demineralizersystem neutralization and nonreclaimable waste pumps.

WP 5552-03 — Fieldwork is complete.

ECN 5609 — Evacuation Alarm/Fire Detection Valve 26-290

MP 12387 is 90 percent complete. No work is in progress at this time.

ECN 5609 — Alteration to the Makeup Water Treatment Plant

MP 12576 — Work is approximately 75 percent complete. Hold forElectrical Maintenance to perform breaker tests. Need resolution ofinstrument tab description from Division of Nuclear Engineering.

MP 12633 — Mork is approximately 60 percent comolete. Hold forinstrument tab (478601-928) set point revision

MP 12731 — MP is approximately 60 percent complete. Hold forin trument tab (478601-928) et points. Need connection diagramrevisions from Division of Nuclear Engineering.

MP 12684 — MP is approximately 70 percent complete. Hold forinstrument tab (478601-928) set points. Need connection diagramrevision from Divi ion of Nuclear Engineering.

WP 12665 - MP is on hold for outage and is 95 percent complete.

MP 12682 — WP is on hold for outage and is 80 percent complete.

ECN 5626 — Containment Ladders, Unit 1

Modifications needs additional design information to complete. DNE

needs to issue all drawing" listed on this ECN. Work has not begunbecause of this holdup.

"33"

ll

Other Items cont.

ECN 5841 - Hot Shop Fire Detc tion

WP 12360 is complete. Workplan in closure cycle. Need drawingdeviation completed.

ECN 5935 — Correct Power Block Lighting Deficiencies

WP 12437 is complete. WP 12275 is in work. Need workplan revisionfor FCR 7706 to add approximately 40 more lights. WP 5935-01 is fieldcomplete.

ECN 6057 — Cable Tray Covers

Work is complete.

ECN 6196 — Pressurizer Hangers and Valves

PMT is scheduled for unit 1 restart. Remaining unit 2 work isscheduled for U2C3 refueling outage.

ECN 6357 — Essential Raw Cooling Mater (ERCW) Roof Acce s and Railsfor Security Equipment

WP 12238 is in work and is approximately 40 percent complete.

ECN 6388 — Hydrogen Honitors in Switchyard

WP 12223 — Mork has been stopped duo to a lack of funding.

ECN 6429 — Component Coolin Heat Exchanger B Replacement

Plato head exchanger and frame is complete. Hangers and pipe whichcan be installed prior to outage i" in work. Workplan to remove oldheat exchanger is in review cycle. DNE procuring the remaining neededpiping material. Estimated completion date for nonoutage work isduring the month of October 1988.

ECN 6455 - Upgrade CU-3 Box Battery Packs

MP 12295 is field complete.

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Other Items cont.

ECN 6543 — Install Public Safety Access Portals and Modify EntranceRoad

Work is being held pending the release of drawings from DNE.

ECN 6601 — Removal of Unit 1 Emergency Gas Treatment System (EGTS)Backdraft Dampers

PMT remains to be completed by the Mechanical Test Section. Fieldworkis complete.

ECN 6610 — Modify Air Return Fan Supports

Work is complete.

ECN 6689 — Relocation of Main Steam Power Operated Relief Valves (PORV)

All work is complete for unit 2. Work on unit 1 in calibrationstage. WP 12172 (tubing reroute) is 99 percent complete and holdingfor material consisting of tube fittings and clamps (PR 08-2768).

ECN 6698 — Repull 120-Volt Cables

Work is complete.

ECH 6706 — 79-14 Support Enhancement/Lost Calculations

Repairs continue on unit 1. This project has been combined with thecalculation regeneration project for unit 1. Unit 2 work is completeand workplans are closed. There are 30 modifications in work with 168

complete. In addition, 20 maintenance items are in progress with 607

complete.

ECH 6 739 — A 1 terna te Analysis

All unit 1 modification work has been completed. Review and closurehas begun. Work is in progress on the maintenance items.

ECN 6742 — Install Fuses in Radiation Monitor Power Supply Circuits

Work is complete.

ECH 6761 - East Valve Room (EVR) Blowout Panel

Unit 1 work is complete. Unit 2 wor'k is complete.

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Other Items cont.

ECN 6784 — Documentation to Show pipe Class Break

Final closure is awaiting a revision to AI-19 deleting requirements tomark shift supervisor drawings.

ECN 6815 — 500ks switchyard Addition

Install 500kV power circuit breaker and associated equipment forbay 1. Retire 16lkV PCB and associated equipment. A total of 10

workplans will be required. Foundations and conduit installation(WP 12654) are complete. MP 12740 for lighting, drain pipe, andsurface ground mat is 80 percent complete. MP 12739 for thestructural steel installation is 95 percent complete. WP 6815-02 is80 porcent complete. MP 6815-01 and WP 6815-03 are 80 percentcomplete. MP 6815-04 and WP 6815-05 for the electrical control board,main relay boards, and the communications room are 90 percentcomplete. WP 6815-06 for the addition of the Franklin solid staterelay cabinets is field complete. The Watts Bar No. 1 line was

energized by bay 1 on June 21, 1988. Energization of the Franklinline has been delayed because of problems with an existing powercircuit breaker (PCB 5028), and because of incorrect supply voltagefor the static relay carrier sets.

ECN 6860 — Control Room Bullet Resistivity — DCR 2268 - ECN 6860

MPs 12602 and 12604 are field complete. WP 12603 is held fordisposition of CAQR 880183. WP 6860-01 is held for material on

Contract 74014A. Essentially all work is complete except for pullhandles, replacement of door closures, and rework of one lockset.Estimated date of completion is September 30, 1988.

MP 12605 is in closure cyclo.

ECN 7078 — Install Hangers — Main Steam Piping

Complete except for final inspections during heatup.

DCN X00006A — Remove Hydrogen Analyzers Tubing

The workplan lacks PMT (SI-219) ~

ECN 7078 - Install Hangers - Main Steam Piping

Complete except for final inspections during heatup.

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ee

Other Items cont.

ECN 7093 — Replacement of F"edwater Pipe

Work is in progress and is 98 percent complete. Remaining work isheld pending maintenance activities.

DCN 2000188 — Install Needle Valve for Hydrogen Analyzers

The workplan lacks PMT (SI-219).

DCN 7D — Hydrogen Analyzer Check Valves

The woekplan lacks PMT (SI-219).

DCN 192 — Pressurizer Loop Seal

Work is complete.

DCN 341 — Pressueizee Drain Pipe/Hangers

Work is in progress.

Instrumentation Verification Peo ram

For unit 2, there have been 953 discrepancies issued to MODS to datewith 476 not required for restart. All discrepancies required foreestart have been completed; 69 nonrestart discrepancies are open.

For unit 1, theee have been 532 discrepancies issued to MODS to datewith 218 not requieed for restart. Of 314 required for restart, allare complete.

DCN 224 — RHR Slope Rewoek

Teain A complete, Train B needs outage.

ECN 7318 — Capillary Tray Hanger Rework

Complete.

DCN 27 — Double Isolation Valves

In work.

ECN 7345 — Valve Shims

Work complete, workplan in closure cycle.

DCN 373 — Flex Hose Rework

In work.

-37-

~ ~

Other Items cont.

DCH 214 — AFH Tap Rotation

Complete, Instrument Maintenance to test.

DCH 242 — Sense Line Hangers

Tn work.

DCH 19B — ice Conden-"ate Expansion Bellows

Work is in process.

DCNs 229 and 231 — H2 Analyzer Modification

Mork is in progress on unit 1.

DCN 300 — ERCM modifi.cation for microbiologically induced corrosion(HIC) A train is complete, B train in work.

Mork is in progress on unit 1.

ECN 6596

MP 12402 - Workplan is closed.

WP 12612 — Complete. " Closure in process. SOIs are complete. SI-743is in the process of being updated by Electrical Maintenance.

-38-

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CORRECTIONS

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Corrections: Please find attached a correction to the June MonthlyOperating Report, page 19. All items with an asterisk (~)were revised.

-39-

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+4

OPERATING DATA REPORT

DOCKET NO. 50-328DATE JULY 25. 1988*COMPLETED DY D- C. DUPRE.f.-TELEPI.IQNE ( 61 5 ) 870-67:>2

OPERATING STATUS

1. UNIT NAME: SEQUOYAH NUCLEAR PLANT> UNIT 22. REP QR T PER IOD: JUNE 19883. l.iCENSED THERMAL POWER (MWT): 3411. 04. NAMEPLATE RATING .<GROSS MWE): 1220. 65. DESIGN ELECTRICAL RATING (NET "lWE): 1148.0

>MAXIMUM DEPENDABLE CAPACITY (GROSS MWE): 1183. 07. MAXIMUM DEPENDABLE CAPACITY (NET MWE): 1148 08. IF CHANGES OCCUR IN CAPACITY RATINGS( ITEMS NUMBERS

3 THROUGH 7) SINCE LAST REPORT> GIVE REASONS:

NOTES:

9. POWER LEVEL TO WHICH RESTRICTED> IF ANY<NET MWE):

10. REASONS FQR RESTRICTIONS> IF ANY:

THIS MONTH YR. -TO-DATE CUMULATIVE

1. l.fDiRS IN REPORTING PERIOD2. Nf;MBER OF HOURS REACTOR WAS CRITICAL

13. ?""'ACTOR RESERVE SHUTDOWN HOURS14. 'HCAJRS GENERATOR ON-LINE15. UNIT RESERVE SHUTDOWN HOURS16. ROSS THERMAL ENERGY GENERATED (MWH)17. GROSS ELECTRICAL El'JERGY GEN. (MWH)18. 'fET ELECTR ICAL ENERGY GENERATED (MWH)l9. UNI T SERVICE FACTOR20. UNIT AVAILABILITYFACTOR21. UNIT CAPACITY FACTOR (USING Mi)C NET)22. UNIT CAPACITY FACTOR (USING DER NET)23. UNIT FORCED OUTAGE RATE24. SHUTDOWNS SCHEDULED OVER NEXT 6 MONTHS

720. 00404. 1$

0. 00314. 77

0. 00820272. 14265390. 00240870. 00*

43. 7243. 7229. 14*29. 14*56. 28

(TYPE> DATE>

4367. 00 .">3328. 00785. 10 22769. 64

0. 00 0. 00680. 75 >2174. 97

0. 00 0. 001600976. 36 70728953. 58

514930. 00 2405>1710. 00417026. 00* 22925171.

60'5.

59 41. 5815. 59 41. 588. 32* 37. 458. 32* 37.

45'4.

41 54. 21AND DURATION l)F EACH):

25. il'-'HUTDOWN AT END QF REPORT PERIOD. ESTIMATFD DATE OF STARTUP:

iTEMS HAVE BEEN REVISEDNOTE lHAT THE THE YR.-TO-DATE ANDCUMULATIVE VALUES HAVE BEEN UPDATED

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